Advanced Petrophysical, Geological, Geophysical and Geomechanical Reservoir Characterization - Key to the Successful Implementation of a Geo-Engineered Completion Optimization Program in the Eagle Ford Shale

Sun, Tie; Merletti, Germán; Patel, Hemali; Graff, Mitchell; Cadwallader, Stephan; Aguirre, Omar; Wampler, Jeff; Gil, Ivan; Sebastian, Herbert M.; Spain, David R.

doi:10.15530/urtec-2015-2152246

Cited by 5 publications

(4 citation statements)

References 10 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The unique characteristics presented by the shale-gas reservoirs lead to a major shift from the traditional petrophysical work flow. The challenges are mainly attributed to the presence of organic material, complex mineral composition, and the multiple pore types and complex distributions in both organic and inorganic constituents (Passey et al 2010;Quirein et al 2010;Sondergeld et al 2010;Ramirez et al 2011;Murphy et al 2013;Loucks and Reed 2014;Sun et al 2015). Because core analyses provide the ground truth for validation of reservoir properties, X-ray diffraction, crushed-core Gas Research Institute, and TOC analysis are particularly indispensable in shale assessment (Passey et al 2010;Quirein et al 2010;Sondergeld et al 2010;Ramirez et al 2011;Sun et al 2015).…”

Section: Introductionmentioning

confidence: 99%

“…The challenges are mainly attributed to the presence of organic material, complex mineral composition, and the multiple pore types and complex distributions in both organic and inorganic constituents (Passey et al 2010;Quirein et al 2010;Sondergeld et al 2010;Ramirez et al 2011;Murphy et al 2013;Loucks and Reed 2014;Sun et al 2015). Because core analyses provide the ground truth for validation of reservoir properties, X-ray diffraction, crushed-core Gas Research Institute, and TOC analysis are particularly indispensable in shale assessment (Passey et al 2010;Quirein et al 2010;Sondergeld et al 2010;Ramirez et al 2011;Sun et al 2015). Full characterization of shale reservoirs requires comprehensive log-suite and core data to fully capture the heterogeneity and complexity of the formation (Passey et al 2010;Quirein et al 2010Quirein et al , 2013Sondergeld et al 2010;Ramirez et al 2011;Sun et al 2015).…”

Section: Introductionmentioning

confidence: 99%

“…Because core analyses provide the ground truth for validation of reservoir properties, X-ray diffraction, crushed-core Gas Research Institute, and TOC analysis are particularly indispensable in shale assessment (Passey et al 2010;Quirein et al 2010;Sondergeld et al 2010;Ramirez et al 2011;Sun et al 2015). Full characterization of shale reservoirs requires comprehensive log-suite and core data to fully capture the heterogeneity and complexity of the formation (Passey et al 2010;Quirein et al 2010Quirein et al , 2013Sondergeld et al 2010;Ramirez et al 2011;Sun et al 2015).…”

Section: Introductionmentioning

confidence: 99%

“…However, neither laboratory measurements nor dipole sonic were available for this study, which made it impossible to achieve porosity or water saturation to determine the fluid volumetrics. Furthermore, rock mechanical properties such as Young's modulus, Poisson's ratio, and brittleness index were unavailable (Rickman et al 2008;Mullen et al 2010;Passey et al 2010;Quirein et al 2010;Sondergeld et al 2010;Ramirez et al 2011;Cipolla et al 2011;Huang et al 2013;Wan et al 2013;Yu et al 2014;Huang and Torres-Verdin 2015;Sun et al 2015). Therefore, we used alternative methods to represent such properties.…”

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

Quantitative Evaluation of Key Geological Controls on Regional Eagle Ford Shale Production Using Spatial Statistics

Tian

Ayers

Sang

et al. 2018

SPE Reservoir Evaluation &Amp; Engineering

View full text Add to dashboard Cite

Summary Recent progress has increased our understanding of key controls on the productivity of shale reservoirs. The quantitative relations between regional Eagle Ford Shale production trends and geologic parameters were investigated to clarify which geologic parameters exercise dominant control on well-production rates. Previously, qualitative correlations for the Eagle Ford Shale were demonstrated among depth, thickness, total organic carbon (TOC), distribution of limestone beds, and average bed thickness with regional production. Eagle Ford production wells are horizontal, but it was necessary to use vertical wells that penetrated the Eagle Ford to map reservoir properties. No wells in the database had both production and geological parameters, and thus geological parameters could not be directly related to individual-well production. Therefore, spatial-interpolation methods derived from the Kriging and Bayesian methods with Markov-chain Monte Carlo (MCMC) sampling algorithms were used to integrate data sets and predict geological properties at production-well locations. The spatial Gaussian-process-regression modeling was conducted to investigate the primary controls on production. Results suggest that the 6-month cumulative production from the Eagle Ford Shale, in barrels of oil equivalent (BOE), increases consistently with depth, with Eagle Ford thickness (up to 180-ft thickness), and with TOC (up to 7%). Also, when the number of limestone beds exceeds 12, production increases with the number of limestone beds. The corresponding significance code indicates that the parameters most significant to production are TOC and depth (which relates to pressure and thermal maturation). Concepts and models developed in this study may assist operators in making critical Eagle Ford Shale development decisions and should be transferable to other shale plays.

show abstract

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Quantitative Evaluation of Key Geological Controls on Regional Eagle Ford Shale Production Using Spatial Statistics

Tian

Ayers

Sang

et al. 2018

SPE Reservoir Evaluation &Amp; Engineering

View full text Add to dashboard Cite

show abstract

Laboratory experiments of field gas huff-n-puff for improving oil recovery from Eagle Ford Shale reservoirs

Sie

Nguyen²

2022

Arab J Geosci

View full text Add to dashboard Cite

Integration of depositional, petrophysical, and petrographic facies for predicting permeability in tight gas reservoirs

et al. 2017

View full text Add to dashboard Cite

Understanding the linkages between grain mineralogy and diagenetic and sedimentary processes enhances the reliability of petrophysical models to predict reservoir deliverability from permeability. Petrographic data within well-defined depositional facies reveal the diagenetic evolution of porosity-permeability relationships. Formation evaluation methods relying solely on petrophysical rock typing are seriously limited when predicting ultimate reservoir performance in complex pore structures. The Almond Formation, Wyoming, is characterized by three depositional facies associations — shoreface, deltaic (bay head and flood tide), and fluvial-coastal plain — which present three distinctive porosity-permeability trends. Textural features resulting from depositional processes, such as grain size and sorting, vary little between facies associations, yet permeability can vary by up to four orders of magnitude for the same porosity value. Differences between petrophysical facies are primarily driven by diagenetic (cementation and grain dissolution) effects on different framework grain compositions (petrographic facies). Therefore, the main difference between the facies associations is diagenetic, due to provenance and transport mechanisms. The characterization of depositional and diagenetic controls on pore geometry allows the narrowing of uncertainty in absolute permeability prediction. We have quantified the relationship between depositional facies, with their specific mineral composition and diagenetic overprint, and the steepness functions in porosity-permeability space. This analysis allowed us to effectively reduce the uncertainty in the prediction of initial gas production from wireline logs.

show abstract

Advanced Petrophysical, Geological, Geophysical and Geomechanical Reservoir Characterization - Key to the Successful Implementation of a Geo-Engineered Completion Optimization Program in the Eagle Ford Shale

Cited by 5 publications

References 10 publications

Quantitative Evaluation of Key Geological Controls on Regional Eagle Ford Shale Production Using Spatial Statistics

Quantitative Evaluation of Key Geological Controls on Regional Eagle Ford Shale Production Using Spatial Statistics

Laboratory experiments of field gas huff-n-puff for improving oil recovery from Eagle Ford Shale reservoirs

Integration of depositional, petrophysical, and petrographic facies for predicting permeability in tight gas reservoirs

Contact Info

Product

Resources

About